april 23, 2014 dswg loads in scedv1 load participation in sced v1 overview & refresher ercot...

April 23, 2014

DSWG Loads in SCEDv1

Load Participation in SCED v1Overview & Refresher

ERCOT Staff

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Loads in SCED v1

• Three-legged stool:– NPRR 555 – Load Resource Participation in SCED– NPRR 532 – Load Resource Participation in Non-spin– Other Binding Document – Aggregate Load Resources

• All were approved in Sept. 2013 and will go live on June 1, 2014– NOTE: ERCOT is proposing modifications to OBD – On TAC agenda for April 24 (tomorrow)

DSWG Loads in SCEDv1April 23, 2014

3 DSWG Loads in SCEDv1April 23, 2014

High-level summary

• Eligibility to participate: LSE QSEs representing Load Resources capable of following 5-minute SCED base point instructions– Existing or new single-site Controllable Load Resources (CLRs)

• SCED qualification will be a new attribute for redefined CLR

– Aggregate Load Resources (ALRs) composed of multiple sites within single ERCOT Load Zone (subset of CLR)

• Will not support direct participation by third-party DR QSEs• Will not support DR with temporal constraints or block energy

bids– If LR’s bid is on the margin, base point instructions could require

LR to move up or down incrementally every 5 minutes to any level between its LPC and MPC

– SCED will honor LR’s telemetered ramp rates


High-level summary (cont.)

• QSEs with LRs in SCED will submit Bids to buy (not Offers to sell)• Bids will reflect LR’s willingness to consume “up to” a specified

five-minute Load Zone LMP• May be a curve or a MW bid at single strike price• Bid will modify the SCED demand curve and have ability to set

price– SCED Generation to be Dispatched (GTBD) will be adjusted to

accommodate LR participation – This will ensure proper price formation and reduce the likelihood of

oscillating dispatch instructions• Bids from LRs capped at the System Wide Offer Cap

– This is to avoid stranded AS and PRC• ‘Bid to buy’ creates settlement outcomes equivalent to the

“volumetric flow” LMP minus G methodology endorsed by TAC, while avoiding need for ERCOT to “send back” the DR value to the LSE

• SCED will dispatch LRs for power balance and congestion management using the applicable Load Zone Shift Factor



• LR benefits and opportunity:– Avoided cost of consumption above specified price– Price certainty due to ERCOT dispatch– Eligibility to provide Non-spin

• Treated similarly to Offline Generation providing Non-spin• Energy Bids will be released to SCED within 20 minutes following

ERCOT deployment of Non-spin

– Eligibility to receive ORDC payments/charges• ORDC price adders (June 1 implementation) will be paid to QSE for any

un-deployed SCED capacity in excess of AS responsibility• QSE will be charged for AS capacity converted to energy by ERCOT• See Protocol Section 6.7.4 Real-Time Ancillary Service Imbalance

Payments or Charge

• Market impacts:– LR Bids may set price in the RTM– No make-whole payments– No load ratio share uplifts to market for DR value

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• For ALRs, participation in SCED and Non-spin are both contingent on validation by ERCOT of the QSE’s telemetry at time of LR qualification, and spot-validation thereafter– For SCED and Non-spin, telemetry will validate against revenue-

grade 15-minute interval meter data– OBD describes this process

• Telemetry from LRs providing Non-Spin must include Scheduled Power Consumption and SPC+2 – Allows baseline-style M&V and verification of AS responsibility– M&V for LR in SCED for energy only does not require use of

SPC and SPC+2 • ALR population management and other data submission

requirements described in PR 117-01 document, here:– http://www.ercot.com/calendar/2014/04/20140409-WMS


http://www.ercot.com/calendar/2014/04/20140409-WMS

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Load Resource Types & Eligible Services

LR Type QualificationEligible Service / Resource Status

Non-Controllable Load Resource (NCLR)

NCLRUnder-Frequency Relay + 10-minute response

RRS (≤ 50%) ONRL

Controllable Load Resource (CLR)

CLRPrimary Frequency Response (PFR) & respond to Reg deployments

Reg-UpReg-Down

ONRGL

CLR PFR & follow SCED 5-minute dispatch RRS ONCLR orONRGL*CLR Follow SCED 5-minute dispatch Non-Spin


Aggregated Load Resource (ALR) may be a CLR or an NCLR

* If carrying Regulation responsibility.

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LRs in Ancillary Services & SCED

• RRS and Non-Spin from CLR will be deployed via economic dispatch of DR capacity via SCED – CLR will have RTM Energy Bid that covers the RRS and/or Non-

Spin capacity released to SCED – Also can optionally bid additional DR capacity for SCED dispatch

• SCED will only consider CLR for dispatch if its telemetered Resource status is ONCLR or ONRGL– Cannot be OUTL if carrying AS responsibility unless QSE moves

responsibility to a different Resource• No change to existing participation in RRS by UFR-type Load

Resources– UFR-LR-RRS may still be deployed manually in EEA 2

• No change to existing ERS


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CLR with Bid to Buy: SCED Objective & Power Balance


• SCED optimization will minimize cost of dispatch of supply and maximize revenue from demand while meeting Power Balance

Minimize { Sum(OfferPricegen * BasePointgen) – Sum(BidPriceLR * BasePointLR) }

• BasePointgen is instruction on how much to produce• BasePointLR is instruction on how much to consume• NPFLR is current telemetered real power consumption• All Resources can follow 5 minute SCED Base Points

• Power Balance Constraint:Supply=Demand

Supply = Sum (BasePointgen)Demand = GTBD = Inelastic Demand + Elastic Demand

Inelastic Demand = GTBD - Sum(NPFLR)

Elastic Demand = Sum (BasePointLR)

Sum (BasePointgen) = GTBD - Sum(NPFLR) + Sum (BasePointLR)

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Example of SCED outcome: CLR with Bid to Buy


t t+5 t+10 t+15 t+20 t+25

LMP 50 200 300 300 200 50

Inelastic Demand 58,500 59,700 60,050 60,125 59,075 58,500

NPF_LR 1,000 1,000 300 0 0 925

GTBD 59,500 60,700 60,350 60,125 59,075 59,425

BP_G1 59,500 60,000 60,000 60,000 60,000 59,500

BP_G2 0 0 50 125 0 0

BP_LR 1,000 300 0 0 925 1,000

• G1 Offer to Sell: 60,000 MW @ $50/MWh• G2 Offer to Sell: 2,000 MW @ $300/MWh• LR Bid to Buy: 1,000 MW @ $200/MWh willingness to consume up to 1,000 MW if

LMP at or below $200/MWh• No ramp rate limitations for any Resource• All Resources follow 5 minute SCED Base Points

• LR Base Point is instruction on how much to consume

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Example of SCED outcome: CLR with Bid to Buy


$/MWh

MW

Supply Curve

Demand Curve

t,t+25

t+5t+10

t+15

50

200

300

59 K 62 K60 K

t+20

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CLR-ALR Telemetry Requirements (1 of 2)

From Protocols 6.5.5.2 as amended by NPRRs 555 & 532:•A QSE representing a Load Resource shall provide the following Real-Time data to ERCOT for each Load Resource. (Net real power consumption, Low Power Consumption (LPC) and Maximum Power Consumption (MPC) shall be telemetered to ERCOT using a positive (+) sign convention):

(a) Load Resource net real power consumption (in MW);(b) Any data mutually agreed to by ERCOT and the QSE to adequately

manage system reliability;(c) Load Resource breaker status;(d) Low Power Consumption (LPC) (in MW);(e) Max Power Consumption (MPC) (in MW);(f) Ancillary Service Schedule (in MW) for each quantity of RRS and Non-

Spin; (g) Ancillary Service Resource Responsibility (in MW) for each quantity of

Reg-Up and Reg-Down for Controllable Load Resources, and RRS and Non-Spin for all Load Resources;


(For purposes of the upcoming examples, net real power consumption = NPF.)

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CLR-ALR Telemetry Requirements (2 of 2)


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Residential CLR-ALR Telemetry Values Example 1

• This example assumes no AS responsibility and no SCED dispatch


Aggregated whole-house Load = MPC = SPC = NPF

MW

Time

DR capability (MW bid)

“Firm load” (not DR-capable)

Aggregated whole-house Load minus DR capability = LPC

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• This example assumes an AS responsibility but no SCED dispatch


Aggregated whole-house Load = MPC = SPC = NPF

MW

Time


If CLR is carrying AS responsibility, SPC+2 values should project MPC/SPC for a point two hours into the future



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• This example assumes an energy-only SCED dispatch (no AS responsibility)


Aggregated whole-house Load = NPF = MPC = SPC

MW

Time



Aggregated whole-house Load minus DR capability = LPC SCED DR obligation

Aggregated whole-house Load = NPF

Baseline = SPC = MPC

SCED Base point sent

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• This example assumes Non-spin responsibility and deployment, with SCED dispatch


MW

Time




SCED DR obligation

Aggregated whole-house Load = NPF

Baseline = SPC = MPC

SCED Base point sent

SPC+2 values will be used by ERCOT to validate baseline

Aggregated whole-house Load = NPF = MPC = SPC

Offline Non-spin deployed

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ALR Telemetry Validation

• The preceding slides assume the ALR telemetry consists of aggregated premise-level Load

• Modifications to the ALR OBD would also permit ALR telemetry to consist of device-level Load


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ALR Telemetry Validation

• Telemetry validation is performed by comparing 15-minute aggregated telemetry to aggregated premise-level meter data– Telemetry values are averaged across the 15-minute Settlement interval– Resource-level data is aggregated from 15-minute revenue-quality

premise-level metering• For each month of participation:

– 90% of NPC telemetry intervals must be within 10% of resource-level interval meter data

• Non-Spin qualification test criteria:80% of SPC+2 telemetry intervals must be within 10% of the corresponding NPC telemetry interval

• For each month of Non-Spin participation:80% of SPC+2 telemetry intervals must be within 10% of the corresponding NPC telemetry interval

• For each interval of a Non-Spin deployment:X% of SPC telemetry intervals and X% of the corresponding SPC+2 telemetry intervals must be within Y% of the ERCOT baseline for that interval


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Telemetry validation for device-level ALR telemetry

• Following are proposed modifications to the OBD• For device-level ALR telemetry, ERCOT will compare aggregated premise-

level 15-minute meter data to the ALR QSE telemetry values. – First step: ensure that telemetered values for NPC, averaged over each 15-

minute interval, do not exceed aggregated premise-level Load. – Then, changes in the magnitude of telemetered device-level Load in

response to SCED Base Point Instructions should be reflected as corresponding changes in the aggregated premise-level interval meter data, as estimated using an applicable ERCOT baseline methodology

– ERCOT will conduct this comparison across all eligible 15-minute Settlement intervals on a monthly basis

• The following intervals will be subject to telemetry validation: – Any intervals in which the ALR was instructed by SCED to reduce to a level

below its SPC by a MW value greater than 10% of the difference between its SPC and its LPC;

– Any intervals in which the ALR was instructed by SCED to increase its consumption to a level greater than 110% of its current NPC;

– Any intervals in which the QSE initiated an out-of-market deployment of the ALR and reported the deployment details to ERCOT, unless the QSE has notified ERCOT of a telemetry failure.


Bid Characteristics and Participation Scenarios

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RTM Energy Bid Characteristics

• The RTM Energy Bid is CLR-specific

• The RTM Energy Bid is used only in the Real-Time Market (SCED)

• The RTM Energy Bid must be submitted before the end of the Adjustment Period for a given Operating Hour

• Bid price cannot exceed SWCAP

• Regulation Up & RRS capacity on bid curve shall be priced at SWCAP


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• The RTM Energy Bid is submitted as a curve having up to 10 points (MW/price combinations)

• The MW range on the bid curve goes from zero to total demand response capability– First bid MW point is at zero MW (left-most point on the bid curve)– Last bid MW point is the total demand response capability (right-

most point on the bid curve)

• The prices on the bid curve from 0 MW to last bid MW are monotonically non-increasing going from left to right– Price at 0 MW is highest– Price at last bid MW is equal to or lower than price at 0 MW– Price in between 0 MW and last bid MW are monotonically non-

increasing


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• The RTM Energy Bid can be submitted with a fixed not-to-exceed price for an “up to bid MW”– This is a submission of a bid curve with two (MW/price) points having

the same price for both MW points.– The first MW point is at 0 MW (left-most point)– The last MW point is the total demand response capability (right-

most point)


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RTM Energy Bid Characteristics: Example Bid Curve


$/MWh

MW

RTM Energy Bid

0

SWCAP

RegUp

Total DemandResponse Capability0

RRS NSpin

SWCAP

26


• There is no mitigation of the RTM Energy Bid in SCED Step 2

• For each SCED run, the RTM Energy Bid is right shifted so that the last MW on the bid curve coincides with the telemetered Maximum Power Consumption (MPC)– By this right shift of the bid curve, if the telemetered Low Power

Consumption (LPC) is less than the first point of the right-shifted RTM Energy Bid, then ERCOT shall create a proxy bid extension from LPC to this right-shifted first point of the bid curve with a price of SWCAP


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RTM Energy Bid: Example Bid Curve Right Shift for SCED use


$/MWh

MW

RTM Energy Bid

0Total DemandResponse Capability

0 $/MWh

MW

Right shiftedRTM Energy Bid

0

MPCLPC

SWCAP SWCAP

Proxy Bid extension

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Scenario 1

• For any SCED intervals that the LR’s bid to buy is greater than the five-minute Load Zone LMP, SCED Base Point will instruct the LR to consume at its telemetered Maximum Power Consumption, subject to ramp rate limitations from its current consumption level (NPF)


ALR CLR(No Non-spin responsibility)

10 MW Firm

5 MW DR-capable

MPC →

LPC →

► $1,000

RTM Bid to Buy

(up to):

Load ZoneLMP

$50

SCED Base Point

MPC► ►

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Scenario 2

• For any SCED intervals that the LR’s bid to buy is less than the five-minute Load Zone LMP, SCED Base Point will instruct the LR to consume at its telemetered Low Power Consumption, subject to ramp rate limitations from its current consumption level (NPF)



10 MW Firm

5 MW DR-capable

MPC →

LPC →

► $1,000

RTM Bid to Buy

(up to):

Load ZoneLMP

$1,500

SCED Base Point

LPC► ►

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Scenario 3

• For any SCED intervals that the LR’s bid to buy is equal to the five-minute Load Zone LMP, SCED may dispatch the LR in either direction (up or down) in increments as small as 0.1 MW, within the bounds of the LR’s telemetered Maximum Power Consumption and Low Power Consumption, subject to its telemetered ramp rate limitations from its current consumption level (NPF)

• In this scenario, the LR sets the Load Zone LMP



10 MW Firm

5 MW DR-capable

MPC →

LPC →

► $1,000

RTM Bid to Buy

(up to):

Load ZoneLMP

$1,000

SCED Base Point

LPC≤ BasePoint ≤ MPC► ►

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Scenario 4a


ALR CLR(5 MW Non-spin

responsibility released to SCED; 5 MW additional DR

capability)

5 MW Firm

MPC →

LPC →

► $5,000

RTM Bid to Buy

(up to):

Load ZoneLMP

SCED Base Point

LPC+5MWsubject to ramp rate limitations from its current

consumption level (NPF)

►5 MW Non-spin

► $1,000

$1,500►

5 MW add’lDR-capable

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Scenario 4b


ALR CLR(5 MW Non-spin

responsibility released to SCED; 5 MW additional DR

capability)

5 MW Firm

MPC →

LPC →

► $5,000

RTM Bid to Buy

(up to):

Load ZoneLMP

SCED Base Point

►5 MW Non-spin

► $1,000

$5,000►

5 MW add’lDR-capable

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Scenario 5

• LR is cleared in Non-Spin in the DAM for six hours, 2-8 PM – BUT….maximum run time is 3 hours

• Real-time energy bid is 5 MW at $1,000 for all six hours• In real time, Non-Spin is deployed and at 4 PM the LZ LMP goes to

$1,500 and LR is dispatched• Prices stay above $1,000 for 4 hours. • In that fourth hour, LR can’t deploy any longer (sets status to

OUTL)– QSE should continue to send accurate telemetry signals even when

LR status is OUTL• QSE must replace the capacity, either with a different Resource or

through a trade – If can’t replace, subject to compliance violation and potential other

penalties• If QSE notified ERCOT earlier of inability to run more than 3 hours,

ERCOT may run a SASM, and QSE replaces capacity at the MCPC cleared in the SASM


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Scenario 6

• Same LR, same energy bid, same scenario as previous• Difference: this time LR does not have Non-Spin responsibility

(did not offer into DAM)• After LR deployed for the three hours LR hits maximum run

time, QSE changes telemetry to OUTL status• SCED can no longer dispatch• QSE should continue to send accurate telemetry signals even

when LR status is OUTL



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april 23, 2014 dswg loads in scedv1 load participation in sced v1 overview & refresher ercot...

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